System and method for fluid treatment

ABSTRACT

A method of treating a fluid, comprising treating a fluid by adding ozone to the fluid and exposing the fluid to ultraviolet radiation, and producing a wellbore servicing fluid using the treated fluid. A mobile apparatus for treating a wellbore servicing fluid, comprising a fluid flow path comprising an upstream end and a downstream end, the fluid flow path being configured to allow passage of the fluid therethrough, an ozone inlet configured to allow introduction of ozone into the fluid flow path, a source of ultraviolet radiation associated with the fluid flow path so that ultraviolet radiation generated by the source of ultraviolet radiation is introduced into the fluid flow path, and wherein the fluid flow path is configured to treat a fluid at a rate of at least about 25 to about 100 barrels per minute.

CROSS-REFERENCE TO RELATED APPLICATIONS

None.

STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT

Not applicable.

REFERENCE TO A MICROFICHE APPENDIX

Not applicable.

FIELD OF THE INVENTION

This invention relates to systems and methods of treating fluidsassociated with wellbores.

BACKGROUND OF THE INVENTION

Suitable fluid supplies are sometimes required to perform wellboreservicing operations and to produce wellbore servicing fluids. However,a fluid supply local to a wellbore may be abundant but nonethelessunusable due to the presence of bacteria, non-beneficial microorganisms,and an undesirable organic composition of the fluid supply. For example,fluids such as produced water and flowback water, each of which may beextracted from a wellbore, may be unusable for wellbore servicingoperations and production of wellbore servicing fluids due to theirundesirable bacteria, microorganism, and organic composition. Further,the fluids may need to be treated prior to disposal due to theirundesirable composition. Accordingly, there is a need for transformingthe sometimes abundantly available but unusable fluids into fluids thatare usable for wellbore servicing operations and for producing wellboreservicing fluids. Further, there is a need for at least partialremediation of such fluid prior to disposal of the fluid to theenvironment.

SUMMARY OF THE INVENTION

Disclosed herein is a method of treating a fluid, comprising treating afluid by adding ozone to the fluid and exposing the fluid to ultravioletradiation, and producing a wellbore servicing fluid using the treatedfluid. Further, the wellbore servicing fluid may comprise a gellingagent, the wellbore servicing fluid may be an aqueous fracturing fluid,the fluid may comprise produced water obtained from the wellbore duringproduction of hydrocarbons from the wellbore, the fluid may compriseflowback water that was introduced into the wellbore as part of aprevious or ongoing wellbore servicing operation, and/or the fluid maybe introduced into the wellbore at substantially the same fluid flowrate as the fluid flow rate at which the fluid may be treated.

Also disclosed herein is a mobile apparatus for treating a wellboreservicing fluid, comprising a fluid flow path comprising an upstream endand a downstream end, the fluid flow path being configured to allowpassage of the fluid therethrough, an ozone inlet configured to allowintroduction of ozone into the fluid flow path, a source of ultravioletradiation associated with the fluid flow path so that ultravioletradiation generated by the source of ultraviolet radiation is introducedinto the fluid flow path, and wherein the fluid flow path is configuredto treat a fluid at a rate of at least about 25 to about 100 barrels perminute. The source of ultraviolet radiation may be electrically powered.The apparatus may further comprise a fluid mixer configured to promoteturbulence of the fluid within the fluid flow path, and/or the apparatusmay be carried by at least one of a truck, a trailer, and a skid. Theapparatus may further comprise an electrically powered ozone generatorconfigured to produce ozone from air or oxygen. The fluid flow path maybe configured to allow passage of between about 10 barrels per minute offluid to about 250 barrels per minute of fluid from the upstream end tothe downstream end. The apparatus may be configured to introduce ozoneand ultraviolet radiation in sufficient quantities relative to aflowrate of the fluid through the fluid flow path so that the fluid maybe transformed from a fluid that may not be suitable for at least one ofdisposal to the environment and use in producing a wellbore treatmentfluid into a fluid that may be suitable for at least one of disposal tothe environment and use in producing a wellbore treatment fluid, and/orthe fluid flow path may be disposed in a fluid circuit that may deliverfluid to the apparatus from the wellbore and may deliver fluid from theapparatus to the wellbore.

Further disclosed herein is a method of servicing a wellbore, comprisingtransporting a fluid treatment system to a location near the wellbore,receiving fluid into the fluid treatment system, adding ozone to thefluid, irradiating the fluid with ultraviolet radiation, passing thefluid treated with the ozone and the ultraviolet radiation out of thefluid treatment system, and delivering the treated fluid into thewellbore. The transporting the fluid treatment system may comprisecarrying the fluid treatment system by truck, aircraft, boat, or othermobile craft. The method may further comprise after treating the fluid,transporting the fluid treatment system away from the location near thewellbore, and/or adjusting at least one of the oxidation dosing rate anda rate of the fluid flow through the fluid treatment system in responseto results of the comparison of the at least one of a chemical oxygendemand (COD) and an oxygen consumption count (OCC), and determining atleast one of a COD and an OCC of the treated fluid.

Further disclosed herein is a method of producing a wellbore servicingfluid, comprising extracting a fluid from a wellbore, and treating thefluid by adding ozone to the fluid and exposing the fluid to ultravioletradiation, and producing a wellbore servicing fluid using the treatedfluid. Further, the fluid may be treated at a fluid flow rate of betweenabout 10 barrels per minute and about 250 barrels per minute and atleast one of a COD and an OCC of the treated fluid may be suitable toproduce a wellbore servicing fluid using the treated water, and/or thetreated fluid may be used to produce a wellbore servicing fluid atsubstantially the same rate at which the fluid may be treated.

Further disclosed herein is a method of treating a wellbore servicingfluid, comprising extracting a fluid from a wellbore, treating the fluidby adding ozone to the fluid and exposing the fluid to ultravioletradiation, and disposing of the treated fluid to the environment.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a simplified schematic view of a fluid treatment systemaccording to an embodiment of the disclosure; and

FIG. 2 is a simplified schematic view of a wellbore servicing systemaccording to an embodiment of the disclosure.

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

In the drawings and description that follow, like parts are typicallymarked throughout the specification and drawings with the same referencenumerals, respectively. The drawing figures are not necessarily toscale. Certain features of the invention may be shown exaggerated inscale or in somewhat schematic form and some details of conventionalelements may not be shown in the interest of clarity and conciseness.

Disclosed herein are systems and methods for transforming a fluidincluding fluid extracted from a wellbore from an unusable state into ausable state for wellbore servicing operations and/or production ofwellbore servicing fluids. In an embodiment, the methods and systemsdescribed herein are utilized to reduce a chemical oxygen demand (COD)of the fluid, which is related to impurities in water that consumeoxygen. These COD impurities may include material derived from naturalsources and material introduced to the wellbore in the form of organicchemicals. These can be dissolved organic compounds, materials that haveeasily oxidizable groups or inorganic materials with redox metal centersthat are in their reduced state. Alternatively, the methods and systemsdescribed herein are utilized to reduce an oxygen consumption count(OCC). The OCC content of the fluid also arises from easily oxidizablegroups in the organic content in the fluid, and is basically areflection of the chemical oxygen demand (COD) of the fluid system.Their difference basically arises from the reagents and procedures ofthe tests designed to measure each of them. While COD is more of alaboratory methodology, OCC is more applicable to the field operations.However, both methods may be amendable to laboratory or field use.Hereinafter, all materials that contribute to the oxygen consumption arecollectively referred to as oxidizable organic contaminants. As will beunderstood by one of ordinary skill in the art, a fluid that containsoxidizable organic contaminants may adversely affect the intendedfunction of the fluid and/or render the fluid unusable for use inwellbore servicing operations and/or for use in producing a wellboreservicing fluid. A greater understanding of some of the problems posedby the presence of organic contaminants in fluids for use in wellboreservicing operations may be found in U.S. Pat. No. 7,332,094 which ishereby incorporated by reference in its entirety. The systems andmethods disclosed herein are directed toward treating fluids includingextracted fluid with both ozone and ultraviolet radiation to alter theorganic composition of the fluid such that its COD and/or OCC arereduced and the problematic oxidizable organic contaminants are likewisesignificantly reduced. The systems and methods disclosed herein maysimilarly be used to remediate the fluid and/or otherwise alter anorganic composition of the fluid into a form more suitable for disposalto the environment. Further, different constituents of the oxidizableorganic contaminants may react to exposure to the ozone and ultravioletradiation differently. Accordingly, treatment of the extracted fluid mayresult in more effectively reducing some constituents of the organiccontaminants while other constituents may be less effectively reducedand/or not reduced at all. The various characteristics mentioned above,as well as other features and characteristics described in more detailbelow, will be readily apparent to those skilled in the art with the aidof this disclosure upon reading the following detailed description ofthe embodiments, and by referring to the accompanying drawings.

As used herein, the term “organic composition” is intended to broadlyencompass the full mixture of organic contaminants of a fluid. Theorganic contaminants described herein include all organic materials,whether introduced to the fluid through natural processes and/orwellbore servicing operations. The organic composition may be describedas comprising, but not being limited to, biological elements such asbacteria and other microorganisms, dissolved and/or entrained organicmaterials, various classes of compounds such as paraffins, aromatics,resins, asphaltenes, and organic components of treatment fluids such asgelling agents, friction reducers, and/or surfactants. Further, as usedherein, the phrase “treating a fluid” and other similar phrases areintended to mean that at least by introducing the fluid to ozone andultraviolet radiation, the fluid is handled, altered, managed, and/ormanipulated physically and/or chemically to reduce bacteria andbiological growth as well as to reduce and/or alter the organiccontaminants of the fluid and/or to otherwise alter an organiccomposition of the fluid to a state that is more amenable to being usedin a wellbore servicing operation and/or being used to produce awellbore servicing fluid.

FIG. 1 is a simplified schematic diagram of a fluid treatment system 100according to an embodiment. Fluid treatment system 100 generallycomprises a fluid flow path 102 that has an upstream end 104 and adownstream end 106. The fluid flow path 102 further comprises ozoneinlets 108, radiation chambers 110, and optionally fluid mixers 112.Ultraviolet radiation sources 114 are associated with the radiationchambers 110 while an ozone generator 116 is associated with the ozoneinlets 108. The ozone inlets 108 may comprise any suitable fluidconnection between the fluid flow path 102 and the ozone generator 116.In this embodiment, the ozone inlets 108 are connected to the ozonegenerator 116 via ozone supply conduits 115. The radiation chambers 110may comprise a fluid chamber sized and configured to house at least aportion of an ultraviolet radiation source 114 so that the fluid flowpath 102 at least partially envelops a portion of the ultravioletradiation sources 114 within the radiation chambers 110. The fluidmixers 112 may be so-called “plate mixers” or other static in-linemixers that serve to induce turbulent mixing of the fluid that mayencounter the fluid mixers 112. Of course, any other suitable methodand/or device for increasing turbulence may be used. The ozone generator116 is generally an electrically powered device configured to produceozone from environmental air supplied to the ozone generator 116.However, in alternative embodiments, the ozone generator 116 may bereplaced by a source of ozone that has been previously produced. Theultraviolet radiation sources 114 are configured as electrically powereddevices, such as ultraviolet emitting lamps. However, in alternativeembodiments, any other suitable on-demand source of ultravioletradiation may be used.

Most generally, system 100 is configured so that as fluid is flowed fromthe upstream end 104 to the downstream end 106, ozone may be added tothe fluid through ozone inlets 108, the fluid may be irradiated withultraviolet radiation emanating from ultraviolet radiation sources 114while the fluid is in irradiation chambers 110, and the fluid may becomemore turbulent in response to interaction with mixers 112. Theabove-described actions serve to provide a powerful oxidizing effect onthe contents of the fluid within the fluid flow path 102. In particular,components of an organic composition may be at least partially oxidizedand/or reduced to reduce and/or alter the COD and/or OCC of the fluid.Further, while the ultraviolet irradiation may be limited to increasingan oxidization effect while the fluid is located within the radiationchambers 110, the ozone introduced through the ozone inlets 108 maycontinue to provide an oxidization effect to the fluid and fluidconduits conducting the fluid even after the fluid has exited the fluidtreatment system 100.

FIG. 1 further shows the fluid treatment system 100 as used incombination with various other wellbore servicing devices. In thesimplified embodiment shown, a pump 118 may be connected to a fluidstorage container 130 via a conduit 122. An output of the pump 118 maybe connected to the upstream end 104 of the fluid flow path 102.Further, the downstream end 106 of the fluid flow path 102 may beconnected to a wellbore servicing fluid generation system 124. Thewellbore servicing fluid generation system 124 may comprise chemicaladditive hoppers, proppant addition equipment, blenders, mixers, pumps,fluid recirculators, and/or any other suitable device for receiving thefluid exiting the downstream end 106 of the fluid flow path 102 andprocessing that fluid into a wellbore servicing fluid, for example, foruse in servicing a wellbore. In this embodiment, the wellbore servicingfluid generation system 124 is connected to a high-pressure pumpingsystem 126 and through a delivery conduit 128. It will be appreciatedthat the systems described above may be configured to use fluid producedfrom a wellbore, treat the fluid using fluid treatment system 100,produce a wellbore servicing fluid using the wellbore servicing fluidgeneration system 124, and deliver the generated wellbore servicingfluid to a wellbore. Further, the treatment system 100 may be portableso that it may be easily transported from one wellbore servicinglocation to another. For example, the fluid treatment system 100 may beconfigured for easy transportation on conventional trucks (i.e.,tractors and trucks), trailers, and/or skids that are easily loaded ontoand off of trucks and trailers. Still further, the fluid treatmentsystem may be portably configured for deployment and delivery to alocation by a helicopter, boat (such as a barge), or any other suitablemobile craft.

In operation of some embodiments, a portable fluid treatment system 100may be transported to a location of a fluid source to be treated. Oncelocated near the fluid source to be treated, the fluid treatment system100 may be coupled to the fluid source. In some embodiments flowbackfluid (such as flowback water) and/or a produced fluid (such as producedwater) stored at the location may be drawn into the conduit 122 byoperation of the pump 118 or by other pumping means (e.g., wellcirculation or flowback loops). The pump 118 may deliver the fluid intothe fluid flow path 102 of the fluid treatment system 100. At variouslocations along the fluid flow path 102, ozone and ultraviolet radiationmay be introduced into the fluid flow path 102, thereby treating thefluid within the fluid flow path 102. Optionally, turbulence of thefluid may be increased by mixers 112 to further enhance the fluidtreatment. It will be appreciated that any number and/or combinations ofozone inlets 108, radiation chambers 110, and mixers 112 may be disposedalong the fluid flow path 102. Further, in an alternative embodiment, arecirculation conduit may be provided to direct some fluid from a firstlocation within the fluid flow path 102 to a second relatively furtherupstream location within the fluid flow path 102. Such recirculation mayincrease turbulence and/or may be controlled to increase a level oftreatment of the fluid. In an embodiment, the flowback fluid (such asflowback water) and/or a produced fluid (such as produced water) storedat the location in container 130 may also contain water from othersources such as surface water, well water, run-off water, and municipalwater.

FIG. 1 shows a fluid being pumped from a storage container 130, treatedby fluid treatment system 100, incorporated into a wellbore servicingfluid by wellbore servicing fluid generation system 124, and ultimatelymay be returned to a wellbore. However, the fluid treatment system 100may be used to treat fluids for storage and/or may be used in asubstantially closed fluid circuit with a single wellbore. In someembodiments, the fluid treatment system 100 may be configured to treatfluid at a fluid flow rate of between about 10 to about 250 barrels perminute, alternatively between about 40 to about 100 barrels per minute.In some embodiments, the fluid treatment system 100 may be used to treatfluids at a fluid flow rate substantially equal to the fluid flow rateof a wellbore servicing operation. For example, the fluid treatmentsystem 100 may be used to receive and treat fluids at a ratesubstantially equal to a demand for the fluid required by a wellborefracturing operation.

In some embodiments, the fluid treatment system may be used toeffectively treat fluids at the above-described rates even though thefluid enters the fluid treatment system 100 having a turbidity of aboutbetween about 0 to 2,000 Nephelometric Turbidity Units (NTUs),alternatively between about 0 to about 300 NTUs, alternatively betweenabout 100 to about 200 NTUs, alternatively about 150 NTUs. In someembodiments, a fluid may be treated to reduce the COD and/or OCC of thefluid for disposal into the environment. In such cases, repetitiveand/or looping treatment (i.e., recirculating already treated fluid backthrough the fluid treatment system 100 multiple times) of a fluid mayeventually completely or nearly completely remediate the fluid fordisposal to the environment. In other embodiments, a fluid may beconsidered effectively treated when the COD and/or OCC of the fluid isreduced to at least 30% of its original value. An example where such avalue of the COD or OCC may provide an appropriate measure of treatmentsuccess for the fluid may arise where the fluid is to be subsequentlyused to produce a wellbore servicing fluid. For example, if the fluidtreatment system 100 is to treat a fluid that will be used to create agelling fluid, it may be desirable for the treated fluid to comprise aCOD and/or OCC that will not substantially adversely affect theingredients used to generate or break the gelling fluid. By lowering theCOD and/or OCC of the treated fluid, predictability in the performanceof the gelling fluid and/or the breakers used to oxidize (break) thegelled fluid may be maintained because the organic composition of thetreated fluid will not inadvertently degrade, interact, or otherwiseinhibit the intended function of the gelling fluid and/or breakers. Inother embodiments, the COD and/or OCC of the treated fluid may bereduced only enough to prevent a substantial degradation in performanceof the resulting wellbore servicing fluid generated using the treatedfluid.

In other embodiments, the fluid treatment system 100 may be described asconfigured to treat a fluid using so-called “oxidation dosing.” In thisembodiment, oxidation dosing may be accomplished by administering an“oxidation dose” that generally comprises the above-described addedozone as an “ozone dose” to the fluid and the above-describedadministered ultraviolet radiation as a “radiation dose” to the fluid.The oxidation dosing, in some embodiments, may comprise intermittentadministration of ozone and ultraviolet radiation to the fluid. In otherembodiments, the oxidation dosing may be accomplished by administeringthe ozone and the ultraviolet radiation at an “oxidation dose rate.” Insome embodiments, the oxidation dose rate may be provided in a mannerindependent of the rate of fluid passing through the fluid treatmentsystem 100. In other embodiments, the oxidation dose rate may beadministered in response to or to account for a rate of fluid passingthrough the fluid treatment system 100. For example, the oxidation doserate may be proportionally, linearly, or non-linearly adjusted inresponse to a change in the rate of fluid passing through the fluidtreatment system 100. In an embodiment, the oxidation dose rate may betuned to the COD and/or OCC of the water to be treated. Water withhigher COD and/or OCC levels may be treated with higher oxidation doserates. Using the above-described oxidation dosing, a strength of thetreatment may be controlled and/or adjusted to selectively treat thefluid. In some embodiments, oxidation dosing may be accomplished byadministering ozone only.

In some embodiments, the effectiveness of the treatment of the fluid maybe measured and/or otherwise quantified by testing the fluid both beforeand after treatment. For example, each of a sample of untreated fluidand a sample of treated fluid may be analyzed for their total organiccarbon (TOC) content. In response to a change in TOC content, theoxidation dosing rate, a rate of fluid passing through the fluidtreatment system 100, and/or both may be adjusted and/or controlled toachieve a desired change in the TOC content. In some embodiments, afluid may be considered successfully treated when a treated fluid isdetermined to have a TOC content at or below a threshold level.Alternatively, a fluid may be considered successfully treated when atreated fluid comprises a TOC of about a desired percent reduction froma TOC content of the fluid prior to treatment.

In some embodiments, the effectiveness of the treatment of the fluid maybe measured and/or otherwise quantified by testing the fluid both beforeand after treatment. For example, each of a sample of untreated fluidand a sample of treated fluid may be analyzed for their COD, OCC, and/orTOC. In response to a change in COD, OCC, and/or TOC, the oxidationdosing rate, a rate of fluid passing through the fluid treatment system100, and/or both may be adjusted and/or controlled to achieve a desiredchange in the COD, OCC, and/or TOC. In some embodiments, a fluid may beconsidered successfully treated when a treated fluid is determined tohave a COD, OCC, and/or TOC content at or below a threshold level.Alternatively, a fluid may be considered successfully treated when atreated fluid comprises a COD, OCC, and/or TOC of about a desiredpercent reduction from a COD, OCC, and/or TOC content of the fluid priorto treatment.

Further, a fluid may be considered successfully treated and considereduseable for wellbore servicing operations and/or for use in producing awellbore servicing fluid when, after exposure to a predeterminedoxidation dose and/or at a predetermined oxidation dosing rate, theamount of reduction of COD, OCC, and/or TOC content is less than athreshold amount of reduction. In such an embodiment, the failure of aCOD, OCC, and/or TOC content of a fluid to be reduced in response to aknown oxidation dosing and/or oxidation dosing rate may serve toindicate that the remaining organic contaminants are of such compositionthat the remaining organic contaminants are not so harmful to a wellboreservicing operation or to the production of wellbore servicing fluid asto consider the treated fluid unusable. In other words, by measuring aCOD, OCC, and/or TOC content of the fluid before and after treatment, itmay be determined that while organic contaminants remain in the treatedfluid, the remaining organic contaminants may be (as indicated by theirresistance to oxidation) unlikely to easily cause undesirable oxidationreactions while performing a wellbore servicing operation and/orproducing a wellbore servicing fluid using the treated fluid.

The procedure for determination of the chemical oxygen demand (COD) hasbeen described by Andrea M. Jirka and Mark J. Carter (“MicroSemi-Automated Analysis of Surface and Wastewaters for Chemical OxygenDemand”, Analytical Chemistry, Vol. 47, No. 8 (1975), 1397.Additionally, a modified COD method for waters with high chlorideconcentrations may be found in “Dichromate Reflux A Proposed Method forChemical Oxygen Demand Chloride Correction in Highly Saline Wastes” byFrank J. Baumann in Analytical Chemistry, Vol. 46, No. 9 (1974) 1337.Oxygen consumption count (OCC) is a parameter that reflects the amountof oxidizable content in the water. It is defined as the excess ammoniumpersulfate required to break a 40 lb/1000 gal guar gel in a fluid, e.g.,in produced water, to a viscosity of less than 10 cps in a 2-hour timeperiod at 120° F., compared to the amount of ammonium persulfaterequired reduce the viscosity to less than 10 cps using a solution of 40lb/1000 guar in purified water at the same reaction conditions.

OCC or oxygen consumption count may be mathematically represented asfollows:

OCC=X−Y

Where:

Y=amount of ammonium persulphate needed to break 40 lb guar gel insample water to less than 10 cps under reaction conditions;

X=amount of ammonium persulphate needed to break 40 lb guar gel inpurified water, to less than 10 cps under reaction conditions; and

Reaction conditions for OCC may be: Temperature=120° F.,Pressure=Atmospheric, and Time=2 hours.

In an embodiment, the method involved in treating and using a fluid maycomprise: testing the untreated input fluid to measure its OCC;determining a treatment dosage for ozone and/or UV irradiation that isbased on the OCC readings taken in the earlier step; and treating thefluid using at least one of the estimated ozone and UV irradiationdosages; and optionally testing the fluid again to measure its OCC aftertreatment. In an embodiment, a subsequent a treatment dosage of ozoneand/or UV irradiation may be estimated and the fluid may be treatedaccording to the estimated dosage. In an embodiment, a final OCC may beused to appropriately increase the amount of breaker materials added tothe final fluid formulation.

Example 1

Referring to FIG. 2, a wellbore servicing system 1100 is shown ascomprising an embodiment of a treatment system 100. The wellboreservicing system 1100 is a system for fracturing wells in a hydrocarbonreservoir. In fracturing operations, wellbore servicing fluids, such asparticle laden fluids, are pumped at high-pressure into a wellbore. Theparticle laden fluids may then be introduced into a portion of asubterranean formation at a sufficient pressure and velocity to cut acasing and/or create perforation tunnels and fractures within thesubterranean formation. Proppants, such as grains of sand, are mixedwith the wellbore servicing fluid to keep the fractures open so thathydrocarbons may be produced from the subterranean formation and flowinto the wellbore. Hydraulic fracturing may desirably createhigh-conductivity fluid communication between the wellbore and thesubterranean formation.

The wellbore servicing system 1100 comprises a blender 1114 that iscoupled to a wellbore services manifold trailer 1118 via flowline 1116.As used herein, the term “wellbore services manifold trailer” includes atruck and/or trailer comprising one or more manifolds for receiving,organizing, and/or distributing wellbore servicing fluids duringwellbore servicing operations. In this embodiment, the wellbore servicesmanifold trailer 1118 is coupled to eight high pressure (HP) pumps 1120via outlet flowlines 1122 and inlet flowlines 1124. In alternativeembodiments, however, there may be more or fewer HP pumps used in awellbore servicing operation. Outlet flowlines 1122 are outlet linesfrom the wellbore services manifold trailer 1118 that supply fluid tothe HP pumps 1120. Inlet flowlines 1124 are inlet lines from the HPpumps 1120 that supply fluid to the wellbore services manifold trailer1118.

The blender 1114 mixes solid and fluid components to achieve awell-blended wellbore servicing fluid. As depicted, sand or proppant1102, water 1106, and additives 1110 are fed into the blender 1114 viafeedlines 1104, 1108, and 1112, respectively. The water 1106 may bepotable, non-potable, untreated, partially treated, or treated water. Inan embodiment, the water 1106 may be produced water that has beenextracted from the wellbore while producing hydrocarbons form thewellbore. The produced water may comprise dissolved and/or entrainedorganic materials, salts, minerals, paraffins, aromatics, resins,asphaltenes, and/or other natural or synthetic constituents that aredisplaced from a hydrocarbon formation during the production of thehydrocarbons. In an embodiment, the water 1106 may be flowback waterthat has previously been introduced into the wellbore during wellboreservicing operation. The flowback water may comprise some hydrocarbons,gelling agents, friction reducers, surfactants and/or remnants ofwellbore servicing fluids previously introduced into the wellbore duringwellbore servicing operations.

The water 1106 may further comprise local surface water contained innatural and/or manmade water features (such as ditches, ponds, rivers,lakes, oceans, etc.). Further, the water 1106 may comprise waterobtained from water wells. Still further, the water 1106 may comprisewater stored in local or remote containers. The water 1106 may be waterthat originated from near the wellbore and/or may be water that has beentransported to an area near the wellbore from any distance. In someembodiments, the water 1106 may comprise any combination of producedwater, flowback water, local surface water, and/or container storedwater.

In this embodiment, the blender 1114 is an Advanced Dry Polymer (ADP)blender and the additives 1110 are dry blended and dry fed into theblender 1114. In alternative embodiments, however, additives may bepre-blended with water using a GEL PRO blender, which is a commerciallyavailable preblender trailer from Halliburton Energy Services, Inc., toform a liquid gel concentrate that may be fed into the blender 1114. Themixing conditions of the blender 1114, including time period, agitationmethod, pressure, and temperature of the blender 1114, may be chosen byone of ordinary skill in the art with the aid of this disclosure toproduce a homogeneous blend having a desirable composition, density, andviscosity. In alternative embodiments, however, sand or proppant, water,and additives may be premixed and/or stored in a storage tank beforeentering a wellbore services manifold trailer 1118.

The HP pumps 1120 pressurize the wellbore servicing fluid to a pressuresuitable for delivery into the wellhead 1128. For example, the HP pumps1120 may increase the pressure of the wellbore servicing fluid to apressure of up to about 20,000 psi or higher. The HP pumps 1120 maycomprise any suitable type of high pressure pump, such as positivedisplacement pumps.

From the HP pumps 1120, the wellbore servicing fluid may reenter thewellbore services manifold trailer 1118 via inlet flowlines 1124 and becombined so that the wellbore servicing fluid may have a total fluidflow rate that exits from the wellbore services manifold trailer 1118through flowline 1126 to the flow connector wellbore 1128 of betweenabout 1 BPM to about 200 BPM, alternatively from between about 50 BPM toabout 150 BPM, alternatively about 100 BPM. Persons of ordinary skill inthe art with the aid of this disclosure will appreciate that theflowlines described herein are piping that are connected together forexample via flanges, collars, welds, etc. These flowlines may includevarious configurations of pipe tees, elbows, and the like. Theseflowlines connect together the various wellbore servicing fluid processequipment described herein.

In this embodiment, the wellbore servicing system 1100 further comprisesa fluid treatment system 100 of the type described above. The fluidtreatment system 100 is integrated into the wellbore servicing system1100 in a fluid circuit between the fluid storage container 130 and thewater 1106. As such, the fluid treatment system 100 is configured toaccept fluids from fluid storage and treat the fluids as the fluids passthrough the fluid treatment system 100, and subsequently pass thetreated fluids to the supply of water 1106. In this embodiment, thewater storage contain may comprise fluids from any number of watersources such as water produced from wellbores (produced water), surfacewater, or potable water. Accordingly, FIG. 2 and the description aboveclearly illustrate use of the fluid treatment system 100 in the contextof a wellbore servicing operation, and more particularly, the use of thefluid treatment system 100 in the context of a wellbore fracturingoperation.

At least one embodiment is disclosed and variations, combinations,and/or modifications of the embodiment(s) and/or features of theembodiment(s) made by a person having ordinary skill in the art arewithin the scope of the disclosure. Alternative embodiments that resultfrom combining, integrating, and/or omitting features of theembodiment(s) are also within the scope of the disclosure. Wherenumerical ranges or limitations are expressly stated, such expressranges or limitations should be understood to include iterative rangesor limitations of like magnitude falling within the expressly statedranges or limitations (e.g., from about 1 to about 10 includes, 2, 3, 4,etc.; greater than 0.10 includes 0.11, 0.12, 0.13, etc.). For example,whenever a numerical range with a lower limit, R₁, and an upper limit,R_(u), is disclosed, any number falling within the range is specificallydisclosed. In particular, the following numbers within the range arespecifically disclosed: R=R₁=k*(R_(u)−R₁), wherein k is a variableranging from 1 percent to 100 percent with a 1 percent increment, i.e.,k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, . . . 50percent, 51 percent, 52 percent, . . . , 95 percent, 96 percent, 97percent, 98 percent, 99 percent, or 100 percent. Moreover, any numericalrange defined by two R numbers as defined in the above is alsospecifically disclosed. Use of the term “optionally” with respect to anyelement of a claim means that the element is required, or alternatively,the element is not required, both alternatives being within the scope ofthe claim. Use of broader terms such as comprises, includes, and havingshould be understood to provide support for narrower terms such asconsisting of, consisting essentially of, and comprised substantiallyof. Accordingly, the scope of protection is not limited by thedescription set out above but is defined by the claims that follow, thatscope including all equivalents of the subject matter of the claims.Each and every claim is incorporated as further disclosure into thespecification and the claims are embodiment(s) of the present invention.The discussion of a reference in the disclosure is not an admission thatit is prior art, especially any reference that has a publication dateafter the priority date of this application. The disclosure of allpatents, patent applications, and publications cited in the disclosureare hereby incorporated by reference in their entireties.

1. A method of treating a fluid, comprising: treating a fluid by addingozone to the fluid and exposing the fluid to ultraviolet radiation; andproducing a wellbore servicing fluid using the treated fluid.
 2. Themethod of claim 1, wherein the ozone is added to the fluid prior toexposing the fluid to ultraviolet radiation.
 3. The method of claim 1,wherein the ozone is added to the fluid after exposing the fluid toultraviolet radiation.
 4. The method of claim 1, wherein the fluid isobtained from a wellbore prior to treating the fluid.
 5. The method ofclaim 4, further comprising: delivering the treated fluid to a wellbore.6. The method of claim 1, further comprising: using the treated fluid ina wellbore servicing operation.
 7. The method of claim 1, furthercomprising: producing the treated fluid at a rate of between about 10barrels per minute to about 250 barrels per minute.
 8. The method ofclaim 1, wherein the treated fluid comprises at least one of a COD andan OCC lower than at least one of a COD and an OCC of the fluid prior totreating the fluid.
 9. The method of claim 1, wherein the fluidcomprises a turbidity of greater than about 100 NTUs.
 10. The method ofclaim 1, wherein the treated fluid comprises at least one of a COD andan OCC such that performance of the wellbore servicing fluid is notsubstantially degraded in response to the at least one of a COD and anOCC.
 11. A mobile apparatus for treating a wellbore servicing fluid,comprising: a fluid flow path comprising an upstream end and adownstream end, the fluid flow path being configured to allow passage ofthe fluid therethrough; an ozone inlet configured to allow introductionof ozone into the fluid flow path; a source of ultraviolet radiationassociated with the fluid flow path so that ultraviolet radiationgenerated by the source of ultraviolet radiation is introduced into thefluid flow path; and wherein the fluid flow path is configured to treata fluid at a rate of at least about 25 to about 100 barrels per minute.12. The apparatus of claim 11, wherein the ozone inlet is configured toallow introduction of ozone into the fluid flow path upstream relativeto the source of ultraviolet radiation.
 13. The apparatus of claim 11,wherein the ozone inlet is configured to allow introduction of ozoneinto the fluid flow path downstream relative to the source ofultraviolet radiation.
 14. A method of servicing a wellbore, comprising:transporting a fluid treatment system to a location near the wellbore;receiving fluid into the fluid treatment system; adding ozone to thefluid; irradiating the fluid with ultraviolet radiation; passing thefluid treated with the ozone and the ultraviolet radiation out of thefluid treatment system; and delivering the treated fluid into thewellbore.
 15. The method of claim 14, further comprising: coupling thefluid treatment system to the wellbore to receive fluid from thewellbore into the fluid treatment system.
 16. The method of claim 14,further comprising: prior to delivering the treated fluid into thewellbore, producing a wellbore servicing fluid using the treated fluid.17. The method of claim 14, wherein the ozone and the ultravioletradiation are administered to the fluid at an oxidation dosing ratesufficient to reduce at least one of a COD and an OCC of the fluid. 18.The method of claim 14, further comprising: determining at least one ofa COD and an OCC of the fluid prior to adding ozone to the fluid andirradiating the fluid with ultraviolet radiation.
 19. The method ofclaim 18, further comprising: determining at least one of a COD and anOCC of the treated fluid; and comparing the at least one of a COD and anOCC of the fluid prior to adding ozone to the fluid and irradiating thefluid with ultraviolet radiation to the at least one of a COD and an OCCof the treated fluid.
 20. The method of claim 14, further comprisingperforming a wellbore fracturing service using a fracturing fluid thatcomprises the treated fluid.